Australian distribution network service providers (DNSPs) are grappling with a “critical” lack of visibility across their low-voltage networks as EV adoption accelerates, creating significant risks for infrastructure planning and investment decisions that could either strand assets or block the EV transition entirely.
Dr Kate Thompson, Net Zero Transition consultant at EA Technology, a firm that works with every single DNSP in Australia, has warned that without urgent action to improve network monitoring and data collection, Australian operators risk falling behind international counterparts and failing to meet increasingly stringent regulatory requirements for evidence-based investment justification.
“For DNSPs in Australia, and globally, one of the most critical challenges faced is a lack of clear, granular visibility of their low voltage networks,” Dr Thompson explains.
“Without a source of data to understand the actual status of their low-voltage (LV) networks, it is very difficult to identify where emerging constraints due to growth in load from EV charging actually are.”
The visibility challenge places Australian networks at a disadvantage compared to European counterparts, where LV monitoring is already being rolled out at scale.
However, Australia faces additional complexities that make the data gap even more consequential for network planning and operation.
Australia’s unique challenge: combining EVs with record solar adoption
Australia’s expansive geography creates distinct operational challenges, underscoring the importance of network visibility.
With a larger proportion of rural customers than in Europe, voltage stability and network reliability become increasingly vulnerable on long rural feeders as new EV loads are added.
“This makes LV visibility and proactive management even more critical in these areas,” Dr Thompson notes, highlighting how distance compounds the technical challenges of integrating new loads.
Yet geography represents only part of Australia’s distinctive challenge. The country’s world-leading rooftop solar uptake, which continues to grow at record rates, creates a uniquely complex operating environment when combined with accelerating EV adoption.
“Australian DNSPs also experience the somewhat unique challenge of combining EV adoption with the pressures of a rapid uptake of rooftop solar,” Dr Thompson says.
“This combination introduces increased voltage management issues such as voltage volatility and bi-directional power flows on LV feeders.”
While other countries globally experience similar issues, Dr Thompson emphasises that “the sheer scale of solar adoption per capita within Australia creates a more difficult environment for effective planning and system operation as EV adoption accelerates.”
This dual transition, simultaneous growth in both distributed generation and new electric loads, often requires different planning approaches than networks managing either challenge in isolation.
Regulatory pressure demands evidence-based planning
The visibility and data challenges come at a time when Australian energy regulators are demanding more robust, evidence-based analysis from DNSPs to justify network investment decisions.
This regulatory shift requires networks to move beyond traditional planning assumptions toward empirical approaches that can withstand scrutiny.
“The key to producing more robust network investment decisions is the move away from standardised and broad load-related assumptions,” Dr Thompson begins.
“DNSPs must incorporate real-world data into their planning and forecasting calculations to produce empirical evidence. They must ensure that their assumptions come from clear, traceable sources and produce repeatable results.”
Dr Thompson advocates for a comprehensive planning approach that incorporates both top-down and bottom-up modelling methodologies. Networks should work across a range of planning scenarios, particularly around uncertain forecasts such as distributed energy resource (DER) uptake and climate change projections.
“This will demonstrate broader planning considerations and foresight, improving the regulators’ confidence in the DNSPs’ outlook, considerations around future investment, and support justification for least regrets decisions,” she says.
The emphasis on “least regrets” decisions reflects the dual risk networks face: under-investment that creates constraints and delays EV adoption, or over-investment that leads to gold-plating and unnecessary consumer costs.
2030 deadline demands immediate action on LV analytics
Looking ahead to 2030, when EV adoption is expected to surge significantly, Dr Thompson issues a clear call to action for Australian networks to invest immediately in foundational capabilities that will enable effective planning and operation.
“DNSPs need to invest now in LV analytics to improve visibility,” she emphasises.
“Without LV data, forecasting and investment plans will remain built on broader assumptions.”
The investment in data collection and analytics capabilities serves a dual purpose: improving the accuracy of constraint identification while simultaneously enabling non-traditional solutions that can avoid costly network augmentation.
“This data can then be leveraged to identify opportunities where non-traditional solutions, such as larger transformers or more conductors, no longer need to be the primary consideration for network operators,” Dr Thompson explains.
“Potentially cheaper alternatives, such as off-peak charging incentives, should be enabled to avoid over-investment and increased consumer costs.”
Beyond residential charging patterns, networks must prepare for localised, high-load clusters from public or en-route charging infrastructure. Dr Thompson stresses the importance of early stakeholder engagement and whole-system thinking to optimise these connections.
“Working with wider stakeholders early and taking a whole system approach to identify the best options for electric vehicle connections either through location, size or type (flexible or firm), will minimise network impact and promote quicker, cheaper adoption of EVs,” she says.
The consequences of inadequate preparation extend beyond technical constraints to reputational and policy risks. “Without doing this, DNSPs risk being seen as a blocker to this transition,” Dr Thompson warns.
Translating solar solutions to EV challenges
Drawing on her international experience with EV charging infrastructure deployment, Dr Thompson suggested that Australian DNSPs already possess many of the tools needed to manage EV load growth; they simply need to extend and translate approaches currently utilised for solar PV.
“DNSPs typically have a good understanding of the options available to them to mitigate the impact of load growth due to low-carbon technology connections on low-voltage networks,” she notes.
“Extending and translating approaches utilised for technologies such as solar will be the key to success for Australian network operators.”
Dynamic operating envelopes (DOEs) represent a prime example of this translation opportunity. Currently utilised extensively for rooftop solar in Australia, DOEs could be adapted for EV charging to enable DNSPs to dynamically respond to local constraints driven by load growth.
“It also acts as a key enabler for vehicle-to-grid and vehicle-to-home operational systems, a functionality currently being adopted in Japan, for example,” Dr Thompson says, pointing to international precedents for bidirectional charging integration.
However, she cautions that dynamic charging control must be carefully balanced with consumer needs.
“Use of dynamic charging operation for EVs, however, must be carefully balanced with the consumer’s need to have an appropriately charged vehicle at the point of use. Having their vehicle available when they require it is a non-negotiable for consumers.”
Digitalisation as an enabler, not just a hardware solution
Beyond physical infrastructure and direct control systems, Dr Thompson emphasises the critical role of network digitalisation, digital twins, and advanced modelling capabilities in enabling effective EV integration.
“Often, hardware and direct EV control operations take the main focus for enabling EV adoption,” she observes.
“However, increasing digital modelling capabilities enables DNSPs to better understand the EV charging impact, allowing for improved scenario modelling and more robust planning decisions.”
Digitalisation also enables the development of software tools that can streamline the customer connection process for DER infrastructure, improving the customer experience while reducing administrative burden on networks.
“Enabling customer-centric technology and improving engagement with customers around grid operations will reduce delays, increase customer satisfaction and transition the DNSP as an enabler for EV charging infrastructure,” Dr Thompson concludes.
The message from EA Technology’s work across Australia’s distribution networks is clear: the window for proactive preparation is narrowing.
Networks that invest now in visibility, data analytics, and digital capabilities will be positioned to facilitate the EV transition efficiently and cost-effectively. However, those who delay risk becoming constraints rather than enablers of Australia’s transport electrification.